Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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2/11-5

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/11-5
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
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    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Amoco Norway Oil Company
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    214-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    49
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    18.05.1979
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    05.07.1979
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    05.07.1981
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    22.03.2013
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2945.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    2944.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    106
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY CRETACEOUS
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    RØDBY FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 9' 57.7'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 26' 6.42'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6224781.27
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    527022.05
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    288

  • Wellbore history
    General
    Well 2/11-5 was drilled on the western lobe of the Hod Field to test the Late Cretaceous Chalk section. The well was located 1.8 km SSE of 2/11-2 which tested oil from a very thin Chalk section of the Lower Hod Formation. Structural interpretations were made showing a NW-SE trending graben traversing the West Hod lobe. Based on a model from East Hod, it was expected that the porous Tor Formation should be preserved below the unconformity within this structure.
    Operations and results
    Well 2/11-5 was spudded with the semi-submersible installation Dyvi Alpha on 18 May 1979 and drilled to TD at 2945 m in the Early Cretaceous Rødby Formation. No significant problem was encountered in the operations, however six days were spent repairing the BOP stack before it could be run and two days were spent while mixing oil-based mud. The well was drilled with seawater, bentonite and CMC EHV down to 1285 m, with gyp/CMC mud from 1285 m to 2320 m, with lignosulphonate mud from 2320 m to 2765 m, and with oil based "Oilfaze" mud from 2765 m to TD.
    The Paleocene Ash Marker (Balder Formation) was encountered at 2715 m; 105 m low to prognosis. The top of the Chalk Group, Ekofisk Formation was encountered at 2822 m; 117 m low to prognosis. In total, the Chalk section was found to be 98 m thick, whereas 300 m was predicted. These discrepancies reflect the effects of the shallow gas in the area on the seismic data. The velocity corrections which were applied to the seismic were too large. As a consequence, the Chalk Group within the Graben was found below the oil-water contact of the area and no moveable hydrocarbons were encountered. Frequent oil shows were reported however, starting in the upper part of the Hordaland Group:
    1470 - 1575 m: Appr.100% dull yellow fluorescence w/slow white streaming cut, strong odour.
    1575 - 1760 m: 20-100% dull yellow fluorescence w/slow white streaming cut, large pieces bleeding gas.
    1760 - 2050 m: 5-20% dull yellow fluorescence w/slow white streaming cut.
    2050 - 2715 m: 100% dull to golden yellow fair to good fluorescence; moderate to fast streaming white cut; fair to good oil stain.
    2715 - 2737 m: 20-50%, fair dull golden fluorescence and fair cut.
    2825 - 2900 m: 20-80%, dull yellow/ orange fluorescence. No to fair cut.
    No conventional cores were cut in well 2/11-5. Out of 25 sidewall cores 17 were recovered in the Late Cretaceous chalk. No wire line fluid samples were taken.
    The well was permanently abandoned on 5 July 1979 as a well with shows.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    165.00
    2867.50

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    94
    1475
    2715
    2715
    2737
    2822
    2822
    2835
    2855
    2920
    2920

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    1.95
    pdf
    14.15
    pdf
    0.73

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC AL IEL GR SP
    168
    356
    BHC AL IEL GR SP
    295
    766
    BHC AL IEL GR SP
    1274
    2777
    BHC AL IEL GR SP
    2690
    2943
    CBL VDL GR CCL
    1
    1250
    CBL VDL GR CCL
    2000
    2723
    CDL CDN GR CAL
    0
    0
    DIP
    1277
    2645
    DIP
    2765
    2943
    VELOCITY
    146
    2901

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    170.0
    36
    172.0
    0.00
    LOT
    SURF.COND.
    20
    351.0
    26
    358.0
    1.48
    LOT
    INTERM.
    13 3/8
    1278.0
    17 1/2
    1278.0
    1.92
    LOT
    INTERM.
    9 5/8
    2768.0
    12 1/4
    2781.0
    1.84
    LOT
    OPEN HOLE
    2945.0
    8 1/2
    2945.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    358
    1.04
    35.0
    waterbased
    1170
    1.07
    30.0
    waterbased
    1683
    1.59
    38.0
    waterbased
    1980
    1.72
    75.0
    waterbased
    2387
    1.75
    95.0
    waterbased
    2707
    1.80
    52.0
    waterbased
    2781
    1.74
    56.0
    waterbased